Tubing support and tubing hanger



Sept. 1957 I R. E. BENDER EIAL 2,806,535

TUBING SUPPORT AND TUBING HANGER Filed Dec. 1'7, 1952 I FIG. 5.

INVENTORS R.E.BENDER, E.L.BRANUM W.B.BUCK, H.T.OL|PHANT F/G.4.BY Y

F I6. I. :M M I ATT RNEY United States Patent TUBING SUPPURT AND TUBING HANGER Ralph E. Bender, Ernest L. Branurn, and William B. Buck, Oklahoma City, Okla, and Harbin T. Oliphant, Big Springs, Tern, assignors, by direct and mesne assignments, of one-half to Phillips Petroleum Company, a corporation of Delaware, and one-half to Lane-Wells Company, a corporation of California Application December 17, 1952, Serial No. 326,534

19 Claims. (Cl. 166-115) This invention relates to well tools adapted to be fixed in the Well pipe, or casing, where they act as a tubing hanger, tubing anchor, or other support for pipe or casing, to tubing hangers adapted to rest on such supports.

When an oil well is drilled in a field in which there is suflicient pressure in the oil to force it up and out of the well, it is usual to have the well lined with a casing, and then suspend a tubing of smaller diameter in the casing, and flow the oil through the tubing, as this practice reduces the ratio of gas to oil produced. A packer is secured to the lower end of the tubing to pack off the annular space between the casing and tubing to permit the reduction of casing head pressure. This packer is designed to act as a tubing anchor, or support, to support some of the weight of the tubing.

When the well ceases to flow, this tubing and packer are removed and tubing provided with a pump at its lower end is substituted. N0 packer is desired, as during pumping it is preferred to remove gas through the annulus around the tubing. This deep well pump is generally operated by sucker rods coming from the top of the well, but even if operated by electric current, a rotating shaft, or a column of pressure fluid, the operation of such a pump at the bottom of a long tubing only supported at its top would cause undue vibration, failure due to fatigue, and loss of power. Therefore it is necessary to also support the tubing at the bottom of the well by an anchor, which will pass gas up the annulus.

In the prior art these flowing and pumping operations have been done with entirely separate supporting means, which is expensive and disadvantageous especially as such supporting means become very hard to remove. In the present invention the same supporting means is used at all times and need never be removed. It can be removed by drilling it out, however.

As explained above, prior art tubing anchors are secured to the tubing, and must be removed therewith when the tubing is removed from the well for any purpose, such as repair or replacement of parts in the'well.

However, it often happens that condtions are such that pulling the anchor is a very diflicult and costly procedure and in extreme cases has proved to be im possible, causing wells to be abandoned. An example occurs in the Oklahoma City field, where it sometimes happens that the well casing collapses at a point above the anchor. When this occurs the sequence of events is as follows:

1. Shale coming in through the breaks in the collapsed casing causes a bridge to form on the tubing anchor which is set below the collapsed portion.

2. The tubing is perforated above the bridge and a cement plug spotted.

3. The tubing is cut oil above the cement plug and pulled.

4. The collapsed casing is swaged out to full internal diameter. (This is diflicult due to the casing tending to spring back in.)

'5. The casing is squeeze cemented at the collapsed portion until all outside fluid is shut off.

6. The cement is drilled out, the hole bailed dry and the squeeze cementing job is tested.

7. The tubing stub is washed over to the anchor, thereby removing the shale bridge, the hole again bailed dry, and the tubing and anchor fished, and the casing must remain swaged out almost in order to remove the anchor through it.

8. A plug is placed in the bottom of the casing and the casing filled with mud.

9. A protective string of casing is run through the damaged portion and cemented in place.

10. The cement remaining in the protective string and the plug in the original pipe are drilled out.

11. The well is cleaned out.

Through the use of our new drillable pipe support the sequence of events is as follows:

1, 2 and 3. Same as above.

4. The casing is swaged out only enough to allow passage of the protection string of pipe. The tendency to spring back is therefore much less, and the casing remains the new size.

5. The protective string is run and cemented in place.

6. The cement in the protective string is drilled out.

7. The tubing stub is washed over to the anchor, removing the shale, the hole bailed dry, and the tubing fished.

9. The tubing support is drilled out.

9 The well is cleaned out.

Through the use of the drillable support the cost of reconditioning a well is often reduced by as much as 50% The prior art type of anchor also becomes stuck very frequently due to rust in the casing even when the casing is not collapsed, thus causing expensive fishing jobs. The new tubing support will eliminate these fishing jobs.

One object is to provide an improved tubing support, or anchor, for use in flowing and in pumping walls.

Another object is to provide such a support to which the tubing is not attached.

Another object is to make such a support completely drillable.

A further object is to be able to set such a support and remove its body, leaving a suitable support having a much larger diameter central passage than is possible with the devices of the prior art.

Further objects are to provide a simple, rugged and easily operated support which is designed to simplify well operations in any Well in which it is used.

Numerous other objects and advantages will be apparent to those skilled in the art upon reading the accom panying specification, claims and drawings.

Figure 1 is a cross-sectional schematic view of a well containing a casing in which the well tool of the present invention is being set by the means shown.

Figure 2 is a quarter sectioned elevational view of a well tool embodying the present invention with parts broken away to show details of construction.

Figure 3 is a fragmentary elevational view of a tubing and a tubing hanger adapted to be used in combination with the well tool of Figure 2, with a portion of the ring broken away to show details of construction.

Figure 4 is a fragmentary elevational view of the lower portion of the tubing shown in Figure 3.

Figure 5 is a fragmentary elevational view of a packer which is attached to the tubing between Figures 3 and 4 when it is desired to pack between the tubing and the well tool of Figure 1, but which is omitted when it is desired to allow gas to pass between them, with parts broken away to show details of construction.

In Figure 1 a well tool, generally designated as 6, is being run in a well 7 in the ground 8 which well contains a casing 9. Casing 9 may be the only casing in well 7, or there may be several concentric strings of easing (not shown) with 9 as the innermost, in which case casing 9 need not extend to the well surface as shown. The casing 9, or other outer casing strings (not shown) may be provided with the usual well casing head equipment (which is not shown for purposes of simplification). Such arrangements are well known to those skilled in the art of Well servicing operations.

Casing 9 may be in a number of sections secured together by easing collars 10, which are usually external as shown, but may be internal (not shown) as known in the prior art.

Similarly all other features of the usual Well servicing derrick, rig, or mobile unit are not shown, except draw works, or winch, 11, containing means to rotate drum 12 to raise and lower electric cable 13 wound thereon, crown block 14 supporting sheave 16 over the well 7, depth measuring revolution counter 17 driven by drive pulley 18 during movement of cable 13 by contact therewith, and weight indicator 19 actuated by weighing means 21 by a telemetering system indicated by dotted line 22. All the parts in this paragraph, along with the well tool setting device generally designated as 23 are old and well known in the prior art for setting well tools similar to 6 in well casings similar to 9.

The end of electric cable 13 on drum 12 has its electrical conducting elements electrically connected to slip rings 24, 26 which rotate with drum 12, and a battery 27, or other suitable direct or alternating current electrical power source may be connected to said slip rings by brushes when switch 28 is closed to actuate a solenoid 29, or other suitable motor, in the setting tool 23. It is obvious that while a two wire system is shown, a single wire system using the ground as a return may be employed if desired.

The setting tool 23 is supported on the other end of cable 13 and well tool 6 is supported by tool 23.

Setting tool 23 is shown containing a tank 31 of compressed gas connected to cylinder 32 by conduit 33, the flow of gas therethrough being controlled by valve 34 actuated by solenoid 29. When gas is admitted to cylinder 32 it raises piston 36 and piston rod 37 relative to the wall of cylinder 32.

The well tool 6 is secured to piston rod 37 by means of a pin 38, or other suitable connection, which may be installed, or removed, when desired, through a pin access hole 39 in the skirt 41 of setting tool 23, which skirt 41 engages the upper tubular member 42 of well tool 6 as shown in Figure 1.

In Figure 2 the well tool 6, embodying the present invention, is shown in considerable more detail than in Figure 1. Well tool 6 comprises in combination a removable body 43, a first tubular member 44 surrounding and slidably mounted on said body and secured thereto by a first frangible connection 46, said first connection being designed to part at a first predetermined force, a first plurality of slips 47 surrounding and slidably mounted on said body and movably mounted at 48 on said first mem her, a first tubular cone or tubular wedge member 49 surrounding and slidably mounted on said body and secured to said first plurality of slips by a second frangible connection 51, said second connection being designed to part at a second predetermined force less than said first force, a rigid tube 52 surrounding and slidably mounted on said body, a second tubular cone or tubular wedge member 53 surrounding and slidably mounted on said body, recesses '54 and 56 in said first and second cones slidably receiving said rigid tube in telescoping relationship, a resilient tube 57 surrounding and slidably mounted on said rigid tube between said cones, a second plurality of slips 53 surrounding and slidably mounted on said body, a third frangible connection 59 securing said second plurality of slips to said second cone, said third frangible connection being designed to part at a third predetermined force less than said first force, a second tubular member 42 surrounding and slidably mounted on said body and secured thereto by a fourth frangible connection 61, said fourth frangible connection being designed to part at a fourth predetermined force "greater than either said second force or said third force, and a final frangible connection 62 on said body adapted to be connected to one part of a setting tool 23 of the type having a first part 37 which is moved in a direction longitudinally of the well relative to a second part 41, said final frangible connection being designed to part at a final predetermined force greater than any of the previously mentioned forces, said second tubular member being adapted to be engaged by a second part 41 of said setting tool movable relative to said first part.

The various elements, such as tubular member 44, have been described as slidably mounted on other elements, such as member 43, which they obviously are, in order to carry out the movements described below, under the subtitle Operation. While they can be quite loose on each other, this does not mean that they are necessarily freely slidable, because some of them can be rather tight on each other, so long as they can be forced, or stripped in telescopic relation to each other by forces less than those which would shear any of the frangible pins 61, 59, 51 or 46 out of their regular turn. Obviously at least the central portion of resilient tube 57 need not slide relative to rigid tube 52 and if the ends of 57 deform enough they need not either.

While a particular specific setting tool 23 has been shown, both for illustrative purposes and because it is actually preferred to use the same, there are other generic setting tools available in the prior art having two parts relatively movable to each other in a direction longitudinal of the well which can be employed in practicing the present invention. The specific setting tool 23 is not a joint invention of the present four inventors and is not claimed per se in the present case, but the generic setting tool is claimed herein as described in this paragraph, as an element in a new combination with the other elements, such as Figure 2, or as that which is needed to carry out a process step in a process claim.

In the preferred construction shown in Figure 2, piston rod 37 has a piston-yoke cylindrical member 63 beveled around the edge of its lower end for easy insertion and having a hole for receiving screw-pin 62, which member 63 is received in a cylindrical socket in connector 64 and secured therein by pin 62 passing through the holes and screwed into a threaded passage 66 in member 64. Preferably pin 62 is frangible and can be sheared by tension on 63 much greater than that necessary to shear pins 46 and 61 and remove body 43 from the well. If it is desired to rely on always recovering body 43 in this manner, pin 62 need not be frangible, but it is wise to make it weaker than piston rod 37 and cable 13 if convenient, just in event the unexpected happens. While member 64 could be made integral with removable body 43, it is preferably separable and connected thereto by screw threads at 67. Tubular member 42 is preferably provided with a conical seat 63 to receive and support the conical surface 69 of ring 71 of the tubing hanger generally designated as 72 in Figure 3.

The preferred means of connecting members 42 and 44 to body 43 is by frangible pins 61 and 46, which may be single pins, or several may be used as indicated by a second pin hole '73 in member 43. Pins 61 and 4-6 may be the same, or of different strength, and preferably have a tapered nose for ease of insertion and corrugated or otherwise enlarged or roughened tail to retain them in place. The preferred means of movably mounting slips 53 and 47 on member 42 and 44 is by means of integral dove tail lugs 43 on the slips held loosely in similarly shaped dovetail slots 74 in the members.

Slips 4'7 and 58 are preferably cylindrical segments preferably made of cast iron having saw teeth cut in their outer faces and being beveled at 77 to act as wedges when driven between cones 49 and 53 and easing 7. Ev: ery part shown in Figure 2 (with the possible exception of parts 37 and 63 which are quite certain to be removable in any event, and part 57 which must be made of some resilient highly distortable material, such as rubber or some synthetic rubber-like polymeric material such as neoprene) should be made of cast iron, or other drillable material, such as brass, bronze or aluminum, and of course parts 37 and 63 could also be drillable material, but need not be as they will always be removable. The edges of slips 47 and 58 can be straight, but preferably are zig zag and overlap as shown for mutual support and mutual Wedging action.

Cones 49 and 53 have an outer conical surface engaging beveled surface 77 of slips 47 and 58, and are preferably beveled at adjacent edge 78 to insure ease of movement on body 43, but beveling 78, like all the other preferred details of construction, is not essential but is merely preferred.

Preferably there is a space 79 both horizontally as well as vertically spacing rigid tube 52 from the cones 49 and 53.

The lower end of tubular member 44 may be beveled by one or more bevels 81, or rounded, to aid in avoiding catching on obstructions, if so desired.

In Figure 3 is shown a tubing hanger generally designated as 72 for supporting the lower end of a tubing 82 on well tool 6 when the latter is set in the Well. This hanger is very simple, and can obviously be made in other similar forms or designs, without departing from the invention. A ring 71 surrounding tubing 82 is secured to the same by a plurality of radial fins 83, leaving a corresponding number of arcuate holes 84 for the passage of gas between the ring and tubing. A portion of ring 71 is broken away to show this and the cross-section of said ring. Ring 71 has a conical surface 69 which rests on and preferably fits conical seat 68 of member 42 of Figure 2. Ring 71 may be secured to fins 83 by welding at 86, and fins 83 may be tapered for guiding past obstructions, or centering in seat 68 by tapered surfaces at 87 and 88.

In Figure 4 is shown the lower end of tubing 82, which may be threaded at 90 in case further sections are attached. While tubing anchor 6 is used near the lower end of tubing 82, it is not necessarily used at the very end, but may have a considerable length of tubing extending below it. Tubing 82 is connected at its upper end to the lower end of tubing 82 of Figure 3, or to the lower end of tubing 82 of Figure 5, depending on whether the packer generally designated as 89 in Figure 5 is used or not.

In Figure 5 the tubing 82' is intended to connect at its top to tubing 82 of Figure 3 and at its bottom to tubing 82 of Figure 4, when the structure of Figure 5 is used. The packer 89 has a cylindrical surface 91 which is adapted to be inserted inside of rigid tube 52 and cone 49 and 53 of Figure 2 after body 43 has been removed. Surface 91 has one or more annular grooves 92 therein in which packing elements, preferably resilient deformable 0 rings 93 are positioned. Rings 93 are preferably made of rubber, or some rubberlike polymerized synthetic material, such as synthetic rubber or neoprene, and are designed to contact the inner surfaces of grooves 92 and parts 49, 52 and 53 preferably without filling grooves 92 completely, as 0 rings seal best against high pressure under such conditions. Other more conventional packing means of the prior art (not shown) may be employed in place of rings 93.

Operation Tool 6 is positioned at a predetermined proper position in casing 9 as shown in Figure 1 by lowering the same in well '7 by means of drawworks 11, sheave 16, cable 13, setting tool 23 and associated parts, the depth being noted on depth meter 1'7. Switch 28 is then closed and current from electrical power source 27 ,actuates motor,

or solenoid, 29 to open valve 34. Gas under pressure in tank 31 then flows through conduit 33 into cylinder 32 where it moves piston 36 and piston rod 37 upwardly relative to skirt 41.

Piston rod' 37 being secured at 62 to body 43, and skirt 41 pressing down on member 42, a shearing force is first placed on shear pin 61, which shears off at a predetermined force, which may for example be 8,000 pounds between body 43 and ring 42. Actually, pin 61 can be eliminated from the tool, if desired, as it is unnecessary if everything goes well, its only real function being to hold ring 42 still in case something unexpected occurs, such as if it were decided to raise the tool 6 again before setting the same and ring 42 accidently hung up momentarily under some obstruction, such as a shoulder on casing 9 where it connected to a casing collar 10. This should not happen, but it would be embarrassing and damaging if: ring 42 moved down under some such small force and set slips 52 prematurely before the tool 6 were properly positioned, and for this reason it is preferred to have shear pin 61 as shown.

Pin 61 having sheared, or never having been present at all, tubular member 42 moves downward forcing slips 58 downward and transmitting pressure on cone 53, packing ring 57, cone 49, slips 47 and ring 44 through frangible machine screws 59 and 51. At the same time body 43, through pin, or pins, 46, places an upward equal and opposite opposing force of reaction on ring 44. Frangible means 51 and 59 are designed to part at a much lower predetermined force than pins 46, parting at 2000 pounds tensile force for example. Slips 58 and cone 53, and slips 47 and cone 49 telescope and wedge together between tube 43 and casing 9 and packer 57 is compressed and deformed outwardly into contact with casing 9 forming a gas tight packing between tube 43 and easing 9. At the same time packer 57 acts as a resilient spring urging cones 49 and 53 apart and under their respective slips 47 and 58 to maintain them wedged against the casing even after the body 43 has been removed, which removal comes later.

If space 79 is provided around tube 52 some edges of packer 57 will also be deformed into it, in which preferred embodiment of the invention the parts 49, 52, 53 and 57 are even more firmly locked together and the gas tight packing elfect is enhanced.

When a much greater predetermined tensile force, for example 8,000 pounds, is generated between collar 44 and body 43 by piston 36 in cylinder 32, the lower frangible pins 46 and the pin in hole 73 shear. While a single pin 46 can be used, several are preferred to avoid any tendency to cant or tilt, ring 44 before slips 47 have set evenly. When several pins are used in place of a single pin 46, the total shearing force of each pin should be less, so that the total force to release 43 from 44 remains the same, 8,000 pounds being given above as an example. Similarly if more pins are used at 61 the total shearing force should remain the same as when one pin is used. Similarly, if more than one pin 51 or 59 is employed at their respective levels, the total shearing force at each level should remain unchanged, being given above as 2,000 pounds as an example. When pins 46 and the pin in 73 have sheared, body 43 is free to move upwardly, and can be removed up out of well 7 by reeling in cable 13 on drum 12, leaving parts 42, 58, 53, 57,52, 49, 47, and 44 set in the well permanently, although being made of drillable material they can be removed when necessary.

Pin 62 never shears if all goes as expected. Sometimes unforeseen difficulties occur, and that is why pin 62 is provided, and why parts 44, 62 and 64 are made of drillable material. Pin 62 can be made to shear only at the greatest tension cable 13 can take within its elastic limit, or can be made to shear above this value near the elastic limit of a cable (not shown) on a fishing tool (not shown) which can be engaged with the projection on the top of setting tool 23, preferably the former.

7 In the absence of the unforeseen, when pins 46, and the pin in 73 shear at 8,000 pounds, body 43 is easily hoisted out without shearing pin 62.. Obviously as pin 62 does not shear off before pins 46 and 73 go, pin 62 in the example given should shear Well above 8,000 pounds.

If well 7 is a flowing well, with sufficient pressure in the formation to flow oil to the surface, the tubing 82, 82, 82 of Figures 3, 4 and 5 is assembled and supported by ring 71 resting on seat 68 and packer "89 packing off the space between tubing 82' and tube 52, while packer 57 packs off between the tube 52 and casing 9. The well fluids flow up tubing 82, 82 and 82 to the surface and are produced into the usual tanks (not shown), while the pressure above the packer 89 in the annulus around'tubing-82 is low.

When well 7 ceases flowing, or if it is 'a pumping well to start with, the tubing 82 is run as shown in Figures 3 and 4, but not using the structure of Figure 5, the usual deep well pump (not shown) is placed in tubing 82, and pumping is carried on with the lower end of the tubing anchored by ring 71 being supported at least as to part of the tubing weight in seat 68, and gas can pass'up the annulus between the casing 9 and tubing82 through 'arcuate spaces 84 for removal in the usual manner known to the art.

Because there is no body 43 to take up space inside the device 6 when it is set, it is possible to run larger casing, tubing, and tools of all kinds including drilling tools, cleanout tools and fishing tools (not shown) through parts 42, 58, 53, 52, 49, 47 and 44, or hang larger tubing 82 on seat 68, or have more gas space between tubing 82 and easing 9, than in the prior art devices, and yet the whole tool 6 can be drilled out without difiiculty anytime it is desired to remove it. Also tool 6 can be used during the flowing life of the well and remain in place during the pumping life.

A specific embodiment of the invention has been illustrated and described but obviously the invention is not limited thereto.

We claim:

1. A tool adapted to be set in a pipe comprising in combination a removable body, a first tubular member surrounding and slidably mounted on said body and secured thereto by a first frangible connection, said first connection being designed to part at a first predetermined force, a first plurality of slips surrounding and slidably mounted on said body 'and movably mounted on said first member, a first tubular wedge member surrounding and slidably mounted on said body and secured to said first plurality of slips by a second frangible connection, said second connection being designed to part at a second pre determined force less than said first force, 'a rigid tube surrounding and slidably mounted on said body, a second tubular wedge member surrounding and slidably mounted on said body, recesses in said first and smond wedge members slidably receiving said rigid tube in telescopic relationship, a resilient tube surrounding said rigid tube between said wedge members, a second plurality of slips surrounding and slidably mounted on said body, a third frangible connection securing said second plurality of slips to said second wedge member, said third frangible connection being designed to part at a third predetermined force less than said first force, a second tubular member supported on said second plurality of slips and surrounding and slidably mounted on said body and secured thereto by a fourth frangible connection, said fourth frangible connection being designed to part at a fourth predetermined force greater than either said second force or said third force, and a final frangible connection on said body adapted to be connected to one part of a setting tool of the type having a first part which is moved in a direction longitudinally of the well relative to a second part, said final frangible connection being designed to part at a final predetermined force greater than any of the previously mentioned forces, said second tubular member being adapted to be engaged by said second part of said setting tool movable relative to said first part.

j 2. A tool adapted-to be set in a pipe comprising in combination a removable body, a first tubular member surrounding and slidably mounted on said body and secured thereto by'a first frangible connection, said first connection being designed to part at a first predetermined force, a first plurality of slips surrounding and slidably mounted on said body "and rnovably mounted on said first member, a first tubular wedge member surrounding and slidably mounted on said body and secured to said first plurality of slips by a second frangible connection, said second connection being designed to part at a second predetermined force less than said first force, a rigid tube surrounding and slidably mounted on said body, a second tubular wedge member surrounding and slidably mounted on said body, recesses in said first and second wedge members slidably receiving said rigid tube in telescopic relationship, a resilient tube surrounding said rigid tube between said wedge members, a second plurality of slips surrounding and slidably mounted on said body, a third frangible connection securing said second plurality of slips to said second wedge member, said third frangible connection being designed to part at a third predetermined force less than said first force, a second tubular member supported on said second plurality of slips and surrounding and slidably mounted on said body and a final frangible connection on said body adapted to be connected to one part of a setting tool of the type having a first part which is moved in a direction longitudinally of the well relative to a second part, said final frangible connection being designed to part at a final predetermined force greater than any of the previously mentioned forces, said second tubular member being adapted to be engaged by said second part of said setting tool movable relative to said first part.

3. A tool adapted to be set in a pipe comprising in combination a removable body, a first tubular member surrounding and slidably mounted on said body and secured thereto by a first frangible connection, said first connection being designed to part at a first predetermined force, a first plurality of slips surrounding and slidably mounted on said body and movably mounted on said first member, a first tubular wedge member surrounding and slid-ably mounted on said body and secured to said first plurality of slips by a second frangible connection, said second connection being designed to part at a second predetermined force less than said first force, a rigid tube surrounding and slidably mounted on said body, a second tubular wedge member surrounding and slidably mounted on said body, recesses in said first and second wedge members slidably receiving said rigid tube in telescopic relationship, a resilient tube surrounding said rigid tube between said wedge members, a second plurality of slips surrounding and slidably mounted on said body, a third frangible connection securing said second plurality of slips to said second wedge member, said third frangible connection being designed to part at a third predetermined force less than said first force, a second tubular member supported on said second plurality of slips and surrounding and slidably mounted on said body and secured thereto by a fourth frangible connection, said fourth frangible connection being designed to part at a fourth predetermined force greater than either said second force or said third force, and a connection on said body adapted to be connected to one partof a setting tool of the type having a first part which is moved in a direction longitudinally of the well relative to a second part, said second tubular member being adapted to be engaged by said second part of said setting tool movable relative to said first part.

4. A tool adapted to be set in a pipe comprising in combination a removable body, a first tubular member surrounding and slid-ably mounted on said body and secured thereto by ,a first frangible connection, said first connection being designed topart at afirst predetermined force, a first plurality of slips surrounding and slidably mounted on said body and movably mounted on said first member, a first tubular wedge member surrounding and 'slidably mounted on said body and secured to said first plurality of slips by a second frangible connection, said second connection being designed to part at a second predetermined force less than said first force, a rigid tube surrounding and slidably mounted on said body, a second tubular wedge member surrounding and slidably mounted on said body, recesses in said first and second wedge members slidably receiving said rigid tube in telescopic relationship, a resilient tube surrounding said rigid tube between said wedge members, a second plurality of slips surrounding and slidably mounted on said body, a third frangible connection securing said second plurality of slips to said second wedge member, said third frangible connection being designed to part at a third predetermined force less than said first force, a second tubular member supported on said second plurality of slips and surrounding and slidably mounted on said body and a connection on said body adapted to be connected to one part of a setting tool of the type having a first part which is moved in a direction longitudinally of the well relative to a second part, said second tubular member being adapted to be engaged by said second part of said setting tool movable relative to said first part.

5. The combination of claim 4 with said pipe, in which the rigid tube is proportioned with enough space between its ends and the ends of the recesses in said wedge members before any frangible connection parts, and said resilient tube is so proportioned relative to the internal diameter of said pipe, that when said frangible connections part said resilient tube will pack off between said pipe and said rigid tube before each end of said rigid tube engages its respective wedge member at the end of the respective recess with which it has telescopic relationship, upon telescoping of said slips into wedging engagement between said wedge members and said pipe.

6. The combination of claim 4 in which said rigid tube is spaced from said wedge members in said recesses both horizontally and vertically by said resilient tube.

7. The combination of claim 4 in which said second tubular member has a conical seat in its upper portion adapted to receive a tubing hanger so that said tool can be used as a tubing anchor.

8. The combination of claim 5 in which said second tubular member has a seat adapted to receive a tubing hanger after the adjacent plurality of slips have set between the pipe and the adjacent wedge member, and said rigid tube has an internal surface adapted after said removable body has been removed to seal against a packer on a tubing supported by said hanger.

9. A tubing hanger comprising in combination a tubing, a plurality of radial fins secured to said tubing, an undercut shoulder in each fin, and an annular supporting ring secured to said fins below and against said shoulders, whereby forces tending to move said ring upwardly relative to said pipe are resisted by said shoulders.

10. The combination of claim 9 in which said ring has a conical downwardly and inwardly tapering surface, and said fins are beveled upwardly and downwardly from adjacent said ring, inwardly to the surface of said tubing.

11. The combination of claim 9 in which said tubing below said ring and fins is formed with an enlarged cylindrical section, annular grooves in said enlarged section, and resilient packing rings mounted in and extending out of said grooves.

12. A tool adapted to be set in a pipe comprising in combination, a first tubular member, a first plurality of slips movably mounted on said first member, a first tubular wedge member secured to said first plurality of slips by a first frangible connection, a rigid tube, a second tubular wedge member, recesses in said first and second wedge members slidably receiving said rigid tube in telescopic relationship, a resilient tube surrounding said rigid tube between said wedge members, a second plurality of slips, a second frangible connection securing said second plurality of slips to said second wedge member, and a second tubular member supported on said second plurality of slips.

13. The combination of claim 12 with said pipe, in which the rigid tube is proportioned with enough space between its ends and the ends of the recesses in said wedge members before any frangible connection parts, and said resilient tube is so proportioned relative to the internal diameter of said pipe, that when said frangible connections part said resilient tube will pack off between said pipe and said rigid tube before each end of said rigid tube engages its respective wedge member at the end of the respective recess with which it has telescopic relationship, upon telescoping of said slips into wedging engagement between said wedge members and said pipe.

14. The combination of claim 12 in which said rigid tube is spaced from said wedge members in said recesses both horizontally and vertically by said resilient tube.

15. The combination of claim 12 in which said second tubular member has a conical seat in its upper portion adapted to receive a tubing hanger so that said tool can be used as a tubing anchor.

16. The combination of claim 13 in which said second tubular member has a seat adapted to receive a tubing hanger after the adjacent plurality of slips have set between the pipe and the adjacent wedge member, and said rigid tube has an internal surface adapted to seal against a packer on a tubing supported by said hanger.

17. The combination of claim 16 including a tubing dis posed inside and passing through said rigid tube, a tubing hanger secured to said tubing and disposed on said seat to support said tubing, and a packer on said tubing disposed to seal between said tubing and said internal surface of said rigid tube when said hanger is disposed on said seat.

18. The combination of claim 16 including a tubing disposed inside and passing through said rigid tube, and a tubing hanger secured to said tubing.

19. The combination of claim 16 including a tubing disposed inside and passing through said rigid tube, and a tubing hanger secured to said tubing and disposed on said seat to support said tubing, said tubing being of smaller diameter than said internal surface of said rigid tube to provide a space for the passage of gas therebetween, and said tubing hanger being provided with a passage for the passage of said gas connecting said space in communication with the interior of said pipe above said tubing hanger.

References Cited in the file of this patent UNITED STATES PATENTS 1,716,245 Shaw June 4, 1929 1,902,075 Howard Mar. 21, 1933 2,013,112 Scott Sept. 3, 1935 2,189,701 Burt et al. Feb. 6, 1940 2,189,703 Burt et a1. Feb. 6, 1940 2,194,331 Strom Mar. 19, 1940 2,358,677 Yancey Sept. 19, 1944 2,602,512 Baker July 8, 1952 

